Method and apparatus for surface-to-downhole communication

ABSTRACT

Downhole operations within a well borehole are controlled by utilization of various communication channels within the borehole. The conditions within these communication channels are detected downhole and are applied to downhole comparators. Whenever the condition with a communication channel is changed by an operator on the earth&#39;&#39;s surface so that it exceeds a reference value, the comparator provides an output signal. A control gate selectively combines the output signals from the comparators to provide control signals for utilization in the control of the downhole operations.

ttes

Patton et a1.

[4 1 Mar. 26, 1974 METHOD AND APPARATUS FOR SURFACE-TO-WNHOLE Sexton; John W. Harrell, both of Duncanville, all of Tex.

Mobil Oil Corporation, New York,

[73] 'Assignee:

3,324,717 6/1967 Brooks et al 175/48 3,461,978 8/1969 Whittle 3,675,727 7/1972 Clark 3,593,807 7/1971 Klima....

3,552,502 l/l97l Wilson l7S/38 Primary ExaminerMaynard R. Wilbur Assistant Examiner-H. A. Birmiel Attorney, Agent, or Firm-A. L. Gaboriault; George W. Hager, Jr.

[22] Filed: July 18, 1972 Downhole operations within a Well borehole are con- [52] trolled by utilization of various communication chan- 328/146 nels within the borehole. The conditions within these communication channels are detected downhole and E; i 'ggi fig E 31f 5 52 9 are applied to downhole comparators. Whenever the e 5 48 5O 166/66 5 condition with a communication channel is changed 328/148 by an operator on the earths surface so that it exceeds a reference value, the comparator provides an output signal. A control gate selectively combines the output [56] References (:med signals from the comparators to provide control sig- UNITED STATES PATENTS nals for utilization in the control of the downhole 3,517,553 6/1970 Williams et a1. 166/66 operations. 3,527,961 9/1970 Palini 328/146 3,728,700 4/1973 Duval 340/421 16 Claim, 10 Drawing Figures so a! 86 MFR 2 300 GPM w MUD FLOW MFR MFR SIGNALS osr c r oR COMPARATOR MFR 2 200 GPM A WE GHT ON WOB IKLB W05 8 CONTROL @Z'fll-J; COMPARATOR W05 2 KLB GATE 2 c RS 5 RPM E DRILL STRINCG R5 R5 ggfiggf, coMPARAToR 5ORPM RS IOORPM COMMUNICATION CONTROL PMENYEBWPS M4 3.800.277

SHEEI 1 UP 6 RECORDER MFR G T MFR DETECTOR W W05 2 IOKLB VR WOB .IOKLB At a 10 SEC METHOD AND APPARATUS FOR SURFACE-TO-DOWNIIOLE COMMUNICATION BACKGROUND OF THE INVENTION This invention relates generally to logging while drilling wherein control of downhole operations within a borehole are effected from the surface of the earth. More particularly, control signals are telemetered to a downhole tool by means of the communication channels afforded by the various operating parameters.

In the past, a conventional practice in the logging of a borehole has been to apply electric current from a suitable source aboveground through an insulated conductor extending into the borehole to sensing apparatus. The sensing apparatus provides a signal in the insulated conductor representative of the characteristic measured within the borehole. The provision and maintenance of such an insulated conductor for logging the borehole while simultaneously drilling the borehole has been found to be impractical.

More recently, logging-while-drilling systems have been employed which do not require an insulated conductor in the borehole at any time for logging operations. In one such system, the sensing apparatus located within the borehole transmits the logging measurements by means of an acoustic wave passing upward through the drill string. An example of such a system is disclosed in U.S. Pat. No. 2,810,546 to B. G. Eaton et al. In another such system the drilling liquid within the borehole is utilized as the transmission medium for the information-bearing acoustic waves. An example of such a system is disclosed in U.S. Pat. No. 3,309,656 to John K. Godbey. In the Godbey system, drilling fluid is continuously circulated downward through the drill string and drill bit and upward through the annulus provided by the drill string and the borehole wall, primarily for the purpose of removing cuttings from the borehole. An acoustic transmitter located downhole continuously interrupts the flow of the drilling fluid, thereby generating an acoustic wave in the drilling fluid. The acoustic wave is modulated with information measured downhole by sensing apparatus, and the modulated acoustic wave is telemetered uphole through the drilling fluid to suitable recording equipment.

In order to control the downhole drilling and logging operations, it has long been the practice to stop the operations and remove the drill string from the well for the purpose of changing or switching from one type of operation to another. The advantages of being able to control and change such downhole operations from the surface of the earth without stopping the operations and removing the drill string from the borehole are obvious.

SUMMARY OF THE INVENTION In accordance with one aspect of the invention, downhole operations, that is, operations at any point along the length of the borehole, are carried out by controlling various conditions within the logging-whiledrilling system. Changes in these conditions are initiated at the surface of the earth and are detected at a downhole location within the borehole. Output signals, produced downhole in response to these changes, are selectively combined to provide for a plurality of control signals which are utilized to control the downhole operations.

In another aspect, the output signals are of a first state when the absolute value of the condition within the communication channel exceeds a reference value and of a second state when the absolute value of the condition within the communication channel does not exceed the reference value.

In a further aspect, the output signals are of a first state when the time integral of the condition within the communication channel exceeds a reference value and of a second state when the time integral of the condition within the communication channel does not exceed the reference value.

More particularly, at least one reference signal is provided for each of the communication channels. Output signals will be produced based upon the comparison of the condition within the communication channel or its time integral with the corresponding reference signal, the output signals for each communication channel being equal in number to the number of reference values provided for each communication channel. These output signals are selectively connected to a plurality of gates which provide the plurality of control signals in accordance with the logic states of the selected out put signals to which they are connected. i

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 illustrates a well drilling system adapted to simultaneously drill and log a well.

FIG. 2 is a cross-sectional view of a borehole logging tool utilized in a loggingwhile-drilling system.

FIG. 3 is a block diagram illustrating the components housed within the borehole logging tool of FIG. 1.

FIG. 4 is a block diagram illustrating the communication control system of the present invention.

FIGS. 5-7 and 10 are detailed electrical schematics of the components of the communication control system of FIG. 4.

FIGS. 8 and 9 illustrate the waveforms of the signals appearing at the designated points in the electrical schematics of FIGS. 5 and 6.

DESCRIPTION OF THE PREFERRED EMBODIMENT In accordance with the present invention a communication control system is provided for controlling the downhole operations at any point along the length of the borehole in a logging-while-drilling system. Signals are telemetered to a downhole tool by means of communication channels which can be controlled either automatically or by an operator from the surface of the earth. Such signals are detected downhole and utilized to provide the necessary control for the downhole operations.

A brief description of a conventional rotary drilling apparatus with which this invention can be used will be given prior to the detailed description of the invention itself. In FIG. 1 there is shown a derrick 20 located over a well 21 being drilled in the earth by rotary drilling. A drill string 22 is suspended within the well 21 from the derrick 20. The drill string 22 includes a plurality of sections of drill pipe with one or more drill collars and a drill bit 23 secured at its lower end and a kelly 24 secured at its upper end. Kelly 24 extends through and is rotatably engaged by rotary table 25. A suitable prime mover (not shown) drives a member 26 which rotatably engages the rotary table 25, thereby rotating the drill string 22 within the well 21. The member 26 is superimposed directly above the wellhead 27. The wellhead 27 is secured to a casing 28 which is cemented into position a short distance into the well 21. A hook 29 is connected to the kelly 24 through a rotary swivel 30. Hook 29 is attached to a traveling block (not shown) which in turn is suspended by a suitable cable (also not shown). The rotary swivel permits rotation of the drill string relative to the hook and traveling block. The swivel 30 also forms a fluid connection between a source of drilling fluid, such as mud, and the drill string 22. A pump 31 transfers the drilling fluid from a pit 32 in the earth through a desurger 33, which is adapted to suppress noise in the drilling fluid, and a flexible hose 34 into the swivel 30. The drilling fluid then flows downwardly into the drill string 22 and exits through openings in the drill bit 23 into the well 21. The drilling fluid then circulates upwardly from the drill bit 23 carrying formation cuttings through the annulus between the drill string 22 and the well 21 to the surface of the earth. A pipe 35 is connected to the easing 28 for returning the drilling fluid from the well 21 to the pit 32.

Located within the drill string 21 near the drill bit is a downhole logging tool 40 which includes one' or more transducers for measuring downhole conditions and an acoustic transmitter which produces an acoustic signal in the drilling fluid representative of the downhole conditions. This acoustic signal is telemetered uphole through the drilling fluid where it is received by one or more transducers 41 mounted on the swivel 30. The signals from transducers 41 are applied to a recording system 42 which provides readout functions representative of the measured downhole conditions.

The downhole logging tool 40 is illustrated in detail in FIG. 2. The downhole logging tool 40 is formed by an inner housing 42 located within an outer housing 43. The inner and outer housings define an annulus 44 through which drilling mud passes during drilling operations. The upper and lower ends of the outer housing 43 are threaded for connection into a drill string. Within the inner housing 42 are contained the operating parts of the logging-while-drilling system, the power source, the modulation section, the acoustic transmitter, and the communication control section.

The power requirements for the acoustic transmitter are derived from a power source comprising the mud turbine 50, the alternator 51, the voltage regulator 52, and the DC/AC inverter 53. The mud turbine 50 is located immediately below the lower section 54 and the alternator 51 is located within the lower section 54. During the drilling operations, drilling fluid, preferably mud", is continuously circulated through the drill bit by a positive displacement pump located aboveground, primarily to remove cuttings from the hole and prevent blowout. There is substantial hydraulic power in this drilling mud. In the logging-while-drilling system, this drilling mud is passed through the annulus 44, and the hydraulic power is converted to mechanical power by means of the mud turbine 50. Mud turbine 50 drives the alternator 51 to convert the mechanical power to AC electrical power. Located within a middle section 55 is the voltage regulator 52 which rectifies and filters the AC power output from the alternator 51 and provides a regulated DC power output. The DC/AC inverter 53 converts the DC power into suitable AC power for starting and operating the acoustic transmitter. The middle section 55 is sealed from the lower section 54 by means of bulkhead 56. The electrical connection from the alternator 51 to the voltage regulator 52 passes through this bulkhead.

Located near and in communication with middle section 55 are the various types of transducers used to convert such downhole conditions as fluid pressures and temperatures, drilling conditions and parameters, and formation characters into analog electrical signals. These analog signals are applied to the modulation section 57 for conversion into digital signals for use in modulating the acoustic transmitter. The collar 58 surrounding the outer housing 43 provides a compartment 59 within which the transducers may be located. The transducers communicate with the modulation section 57 by means of the channel 60 leading from compartment 59 into the middle section 55.

Also located within the middle section 55 is the communication control section 61 which will be described in detail hereinafter.

Located within an uppersection 65 is an induction motor 66 and a drive train 67. An acoustic generator comprising a fixed stator 68 and a rotary valve 69 is located immediately above the upper section 65. These four components, induction motor 66, drive train 67, stator 68, and rotary valve 69, comprise the acoustic transmitter. Rotary motion of the rotary valve 69 is initiated and maintained by the induction motor 66 which is connected rigidly'to the rotating valve through the drive train 67. The induction motor 66 is electrically connected to the DC/AC inverter 53 through the bulkhead 70 which seals the middle section 55 from the upper section 65. The stator 68 and the rotary valve 69 have complementing slots 71 and 72. The rotor is in an open position when the slot 72 is rotated to a position which is in communication with the slot 71 of the stator 68. In this open position, the drilling mud will pass through the slots in the rotor and stator and through the annulus 44 to drive the turbine 50. The hydraulic power in the drilling mud is converted by the turbine 50 to mechanical power which in turn is converted to electrical power for rotating the rotary valve 69. As the valve 69 is rotated, it continuously interrupts the flow of mud, thereby generating the acoustic signal which travels upward through the mud column to the surface of the earth. 7

This acoustic signal may be modulated with the digital signals which represent the downhole condition measurements from the transducers. These digital signals are utilized within the modulation section 57 to control the frequency of the AC power applied to the induction motor 66 and, consequently, the speed of the induction motor. As it is the speed of the induction motor which determines the frequency of the acoustic signal, the acoustic signal is therefore frequency modulated in response to the digital signals representing the downhole conditions measured by the logging transducers. In this manner, modulated, continuous, acoustic waves travel uphole in the drilling mud and are received at the earths surface and demodulated to provide a readout of the downhole conditions.

Referring now to FIG. 3 there are illustrated in flow diagram the details of the borehole logging tool illustrated in FIG. 2. As previously described, the mud turbine 50 converts the hydraulic power in the drilling mud to mechanical power for driving the alternator 51 which, preferably, is a three-phase, six-pole alternator. The three-phase, AC power from the alternator 51 is applied to a voltage regulator 52 which rectifies and filters the AC power output from the alternator 51 and provides a regulated DC voltage output. This regulated DC voltage is converted by a DC/AC inverter 53 into suitable AC power for starting and operating the induc tion motor 66 in the acoustic transmitter,

The downhole measurements of the transducers 76, in analog form, are multiplexed by multiplexers 77 and are coded into binary digital words by an A/D converter 73. Each digital word is converted into serial binary bits by an encoder 74 and applied to motor control 75 which in turn regulates the frequency of the AC power applied from the DC/AC inverter 53 to the induction motor 66, consequently varying the speed of the induction motor 66 and thereby modulating the acoustic signal output from the acoustic generator 78 in accordance with the digital information applied to the motor control circuit 75.

An example of the type of borehole logging tool illus trated in FIG. 2 and discussed so far in relationship to FIG. 3 is set forth in US Pat. No. 3,309,656 to John K. Godbey. For a more detailed description of the mechanical and electrical features of such a borehole logging tool, reference may be had to the aforementioned patent to Godbey.

Having now described both the mechanical and electrical features of an example of a conventional loggingwhile-drilling system to which the communication con trol of the present invention may be best directed, there will now be described in detail, in connection with FIGS. 4-9, a preferred embodiment of the communication control of the present invention.

Referring now to FIG. 4, there is illustrated a block diagram of the communication control of the present invention comprising a mud flow rate detector 80 and a mud flow rate comparator 81, a weight-on-drill-bit detector 81 and a weight-on-drill-bit comparator 83, a drill string rotary speed detector 84 and a drill string rotary speed comparator 85, and a control gate 86.

The flow rate of the drilling fluid, preferably, mud, through the drill string is controlled from the pump 31 on the surface of the earth. This flow rate may be utilized as one of the communication channels from the surface of the earth to the downhole equipment. The mud flow rate detector 80 provides an electrical signal MFR which is proportional to the flow rate of the drilling mud, and such MFR signal is applied to mud flow rate comparator 81. Mud flow rate comparator 81 pro vides, for example, two output signals. The first output signal is present whenever the mud flow rate is equal to or exceeds the rate of 200 gallons per minute. The second output signal is present whenever the mud flow rate is equal to or exceeds a flow rate of 300 gallons per minute.

A weight-on-drill-bit detector 82. provides a WOB signal which is proportional to the weight on the drill bit. This weight is controllable by means of the hook 29 and its associated traveling block (not shown). The WOB signal is applied to weight-on-drill-bit comparator 83 which may, for example, provide two output signals. Thefirst output signal is present whenever the weight on the drill bit is less than 1,000 pounds. The second output signal is present whenever the weight on the drill bit is equal to or greater than 10,000 pounds.

The drill string rotary speed detector 84 provides an RS signal which is proportional to the rotary speed of the drill string. The rotary speed of the drill string is di rectly controllable by means of the prime mover which drives the member 26 which in turn rotatably engages the rotary table 25 for rotating the drill string 22. The RS signal is applied to drill string rotary speed comparator which, for example, may provide two output signals. The first output signal will be present whenever the rotary speed is less than five revolutions per minute. The second output signal will be present whenever the rotary speed exceeds 50 revolutions per minute but is less than revolutions per minute.

Each of the output signals from the three comparators 81, 83, and 85 is applied to a control gate 86. Control gate 86 selectively combines these signals to provide for a plurality of control signals represented by the legends A-E.

It can be appreciated that the mud flow rate comparator 81, for example, may be designed to provide for any number of outputs depending upon the number of mud flow rate levels for which an output signal is desirable, the two output signals for flow rates of 200 gallons per minute and 300 gallons per minute merely being used as examples. Similarly, the weighton-bit comparator 83 and the drill string rotary speed comparator 85 may each be designed to provide for any number of output signals based upon the number of levels of weight on bit and rotary speed for which output signals are desirable.

In like fashion, the control gate 86 may be designed to combine the output signals from the comparators in various selective combinations to provide the desirable control signals, the control signals A-E being illustrative of five such control signals.

It can therefore be seen that the three communication channels illustrated in FIG. 4, that is, mud flow rate, weight on drill bit, and rotary speed of the drill string, may be utilized to provide for a plurality of control signals at a downhole location for controlling the operation of the downhole equipment.

There is illustrated in FIG. 5 the detailed schematic diagram of a mud flow rate detector 80. Input to the mud flow rate detector 80 is supplied by one of the three outputs of the three-phase alternator 51. The frequency of each of the three-phase components of the input voltage is proportional to the speed of the shaft of alternator 51 and, consequently, proportional to the speed of the mud turbine 50. This relationship is as follows:

where,

f= frequency in Hz,

P number of poles, and

M speed of shaft in rpm.

This input is represented by the waveform V, in FIG. 8.

Mud flow rate detector 80 comprises a monostable multivibrator section 100 and a low-pass filter section 101. Monostable multivibrator 100 is biased such that the collector voltage of the output transistor 102 is at zero volts when the multivibrator is in the OFF condition. Each time the input V passes through zero volts in the negative-going direction, transistor 103 is triggered and the monostable multivibrator 100 provides a fixed amplitude and fixed pulse width digital signal V at the output of transistor 102, the period of digital signal V,, thereby being the same as the period of the alternating current input V,,. Digital signal V,,, as illustrated in FIG. 8, varies between the limits of b when the monostable multivibrator 100 is in the OFF condition to a level of when the monostable multivibrator 100 is triggered. Upon triggering of monostable multivibrator 100, the digital signal V,, remains at the b level for a period in the order of one millisecond. Digital signal V,, is applied to the minus input of the inverting amplifier 104 of the low-pass filter section 101. The low-pass filter section 101 generates an output signal V which is a DC voltage with amplitude proportional to the period of the digital signal V,,. Output signal V thereby directly represents the mud tu rbine speed as set forth in Equation (1) above and is therefore proportional to the power available for starting and operating the acoustic transmitter. A sample waveform for the output signal V is illustrated in FIG. 8. The level represents the voltage level at which the turbine reaches a speed representative of a mud flow rate of, for example, 200 gallons per minute, and the level c represents the voltage level at which the turbine reaches a speed representative ofa mud flow rate of, for example, 300 gallons per minute. This output signal V from the low-pass filter section 101 is applied by way of the inverting amplifier 105 as the MFR signal to the mud flow rate comparator 81. a

The weight-on-drill-bit detector 82 provides the WOB signal which is proportional to the weight on the drill bit. This weight is controlled from the earths surface by raising and lowering the hook 29 by means of the associated traveling block (not shown).

As the weight on the drill bit is increased and decreased there are corresponding increases and decreases in strain in the outer housing 43 of the downhole logging tool 40. Such strain may be measured by conventional strain gauges mounted on the outer housing 43 within the compartment 59 formed by the collar 58. The gauges are mounted such that their sensitive axes are along the axis of the borehole tool. These strain gauges communicate with the communication control circuitry 61 within the middle section 55 by means of the channel 60.

There is illustrated in FIG. the detailed schematic of the weight-on-drill-bit detector 82. Two strain gauges 190 and 191 form two opposite legs of a conventional resistive bridge 194. These two strain gauges are mounted on opposite sides of the outer surface of housing 43 within the compartment 59, that is, 180 removed from each other about the housing 43. The two remaining legs of the bridge 194 are formed by resistors 192 and 193. The resistors 192 and 193 are chosen so that the bridge 194 is balanced when the strain gauges 190 and 191 are under a no-load or nostress condition. That is, the voltage V, across the output of the bridge 194 is zero when the weight on the drill bit is zero.

As the weight on the drill bit is increased, there is an increase in compression in the outer housing 43.- The resistance of the strain gauges 190 and 191 changes proportionately with this increase in compression, thereby producing the voltage V across the output terminals of the bridge 1941. The voltage V, is amplified by the inverting amplifier 195 to provide for the WOB signal which is directly proportional to the weight on the drill bit.

Such strain gauges 190 and 191 are state of the art components. A particularly suitable strain gauge is of the foil type in which a thin film of metal is deposited on an insulator. Other types of strain gauges such as wire and semiconductor gauges may also be utilized.

The drill string rotary speed detector 84 provides the RS signal which is proportionalto the rotary speed of the drill string. This speed is controlled from the earths surface by means of a prime mover (not shown) which drives the drill string through the rotary table 25 and the member 26. Such a means for detecting the rotary speed of the drill string is disclosed in US. Pat. No. 3,400,327 to James H. Sexton and Bobbie .l. Pattom The actuaLconditions of the three communication channels, mud flow rate, weight on drill bit, and drilling string rotary speed, are represented by the three signsls MFR, W013, and RS. Other communication channels may be utilized also, but these three are used for illustrative purposes. The three signals MFR, WOB, and RS are then applied, respectively, to comparators 81, 83, and 85. Each of these comparators is illustrated in detail in FIG. 6. The weight-omdrill-bit comparator 83 has the WOB signal applied to the negative input of a unity gain inverting amplifier which serves the function of changing the WOB signal from a positive level to a negative level. The output of amplifier 110 is coupled by way of resistors 111 and 112 to the negative input terminals of inverting amplifiers 113 and 114, respectively. A reference voltage V is applied by way of resistors 115 and 116 to the same negative input terminals of amplifiers 1 13 and 1 14, respectively. This reference voltage Vhd R is a positive voltage. Therefore, initially when there is no weight on the drill bit, the WOB signal is zero and a positive voltage is therefore applied by way of the voltage divider comprising resistors 111 and 1 15 to the negative input terminal of amplifier 113. This sets amplifier 113 to a logic 0 state. As weight is applied to the drill bit, the WOB signal increases in value, thereby causing the voltage level at the output of amplifier 110 to go negative, thereby decreasing the value of the positive input voltage to the negative input terminal of amplifier 113. The resistors 111 and 115 in the voltage divider are sized such that as the weight on the drill bit exceeds 1,000 pounds, the voltage applied to the negative input terminal of amplifier 1 13 becomes negative. At this point the inverting amplifier is switched to a logic 1 state. The output of inverting amplifier 113 is applied by way of inverter 117 to output line 152. As illustrated in FIG. 9 by the waveform WOB 1 KLB, a logic 1 signal appears on output line 152 whenever the weight on the drill bit is less than 1,000 pounds and a logic 0 signal appears on output line 152 whenever the weight on drill bit is greater than 1,000 pounds.

In similar fashion to the operation of amplifier 113, the voltage divider resistors 112 and 116 are sized such that amplifier 114 is set to a logic 0 state so long as the weight on the drill bit is less than 10,000 pounds. As the weight on the drill bit exceeds 10,000 pounds, the amplifier 141 is switched to th logic 1 state. Therefore, a logic 0" signal appears on output line 153 from comparator 83 whenever the weight on the drill bit is less than 10,000 pounds and a logic 1 signal appears whenever the weight on the drill bit is greater than 10,000 pounds. This is illustrated in FIG. 9 by the waveform WOB 1O KLB.

that the negative input terminal to amplifier 122 is supplied with a negative voltage, thereby switching amplifier 122 to a logic 1 state. Therefore, a logic 1 signal appears on output line 151 whenever the mud flow rate is greater than 200 gallons per minute.

in similar fashion, the voltage divider comprising resistors 123 and 124 is such that the amplifier 125 is set to a logic state when the mud flow rate is less than 300 gallons per minute. When the mud flow rate excoeds 300 gallons per minute, the MFR signal increases to a negative level such that the voltage divider comprising resistors 123 and 124 provides a negative signal to the negative input terminal of amplifier 125, thereby switching it to a logic 1 state. Therefore, a logic 1 signal appears on line 150 whenever the mud flow rate exceeds 300 gallons per minute.

The drill string rotary speed comparator 85 is coupled at its input to the RS signal which increases in a negative direction as the rotary speed of the drill string increases. The reference voltage V,, is again a positivelevel voltage and the voltage divider resistors 130 and 131 are chosen such that so long as the rotary speed of the drill string is less than RPM the RS signal is of such a level that the input to the amplifier 132 is a positive voltage, thereby setting amplifier 132 to a logic 0 state. As the rotary speed exceeds 5 RPM, the RS signal increases in the negative direction to such an extent that the voltage divider comprising resistors 130 and 131 applied a negative voltage to the negative input terminal of amplifier 132, thereby switching it to a logic 1" state. The output of amplifier 132 is applied by way of inverter 133 to output line 154. Therefore, a logic 1 signal appears on output line 154 whenever the rotary speed is less than 5 RPM.

Resistors 134 and 135 form a second voltage divider to which the RS signal and the reference voltage signal are applied. Whenever the RS signal is indicative of a rotary speed less than 50 RPM, a positive voltage is applied to the negative input terminal of amplifier 136, setting it to a logic 0" state. When the rotary speed exceeds 50 RPM, the RS signal increases negatively to such an extent that a negative voltage is applied to the negative input terminal of amplifier 136, thereby setting it to a logic 1" state. Resistors 137 and 138 form a third voltage divider to which the RS signal and the reference signal V are applied. So long as the rotary speed is less than 100 RPM, the RS signal is of such a level that a positive voltage is applied to the negative input terminal of amplifier 139, thereby setting it to a logic 0" state. When the rotary speed exceeds 100 RPM, the RS signal increases negatively to such an extent that a negative voltage is applied to the negative input terminal of amplifier 139, thereby setting it to a logic 1" state. The output of amplifier 139 is applied by way of inverter 140 to AND gate 141. Also applied to AND gate 141 is the output of amplifier 136. AND gate 141 provides a logic 1 signal on output line 155 whenever the rotary speed is between 50 RPM and RPM.

It will be noted that Zener diodes 142148 are connected in feedback loops from the output terminal to the negative input terminal of each of the amplifiers 113, 114, 122, 125, 132, 136, and 139. These Zener diodes serve the purpose of preventing the outputs of the amplifiers from going below zero volts or above a positive 5 volts, the outputs thereby being compatible with the input requirements of the logic circuitry of control gate 86.

Each of these outputs from comparators 81, 83, and 85 is applied by way of lines -155 to the control gate 86. it can be noted from the previous description of comparators 81, 83, and 85 that the logic level of the signals on lines 150155 will be at a logic 1 whenever the communication channels are in the conditions represented by the legends identifying the lines 150-155 in FIG. 6. That is, line 150, for example will be at a logic 1 level whenever the mud flow rate is greater than 300 gallons per minute. These six lines 150-155 which represent two conditions for each of the three communication channels, mud fiow rate, weight on bit, and rotary speed of the drill string, are selectively combined within the control gate 86 to provide five control signals A-E. If the mud flow rate is less than 200 gallons per minute, line 151 is at a logic 0 level. Line 151 is applied directly to AND gate 163 and is applied by way of inverter 161 to the reset terminal R of Hip-Hop 160. Line 150 is applied to the SET input terminal S of the flip-flop 160. When the mud flow rate is less than 200 gallons per minute, a logic 1" signal.

is applied to the reset terminal R of flip-flop 160. This resets the 0 output to a logic 0 state. When the mud fiow rate then exceeds 200 gallons per minute, a logic 0 signal is applied to the reset terminal R, thereby removing the reset. When the mud flow rate exceeds 300 gallons per minute, line 150 applies a logic 1 signal to the S input terminal. The Q output terminal of flipfiop is not set to a logic 1 by the leading edge of the logic 1 input to the S terminal. This Q output terminal of flip-flop 160 is applied to AND gate 163. When the mud flow rate exceeds both 200 gallons per minute and 300 gallons per minute, both inputs to AND gate 163 are at a logic 1" level and AND gate 163 provides a control signal A of a logic 1 level. Further, control signal A remains at a logic 1 level so long as the mud flow rate, after initially exceeding 300 gallons per minute, remains above a 200-gallonper-minute level. The flip-flop 160 which was set to a logic 1 state by the mud flow rate exceeding 300 gallons per minute is not reset to a logic 0 state'until the mud flow rate drops below 200 gallons per minute. At this point, the signal on line 151 drops to a logic 0" state and'is applied by way of inverter 161 as a logic 1" reset signal to the reset terminal R of flip-flop 160.

A second control signal B may be produced by combining control signal A with the MFR signal on line 151. Control signal A is coupled by way of line 164 and inverter 165 to one input of AND gate 166. The MFR signal on line 151 is applied by way of line 167 to the other input of AND gate 166. The input to AND gate 166 on line 167 is a logic 1 level whenever the MFR signal on line 151 is at a logic 1" level, indicating that the mud flow rate is greater than 200 gallons per minute. The other input to AND gate 166 is at a logic 1" L than l IfVl:Whfl thecontrolsignal A isat. a; logicil" level,

indicating that'the mud'flow rate has not exceeded 300 I gallons per minute. Control signal B therefore is .at a logic .1 level whenevertheimudtlowJrate .is greater than 200 gallons pe-rminuteand has notexc-ecdedjOG gallons per minute since reaching ute. .1 N

A. third controlsignalC is produced by the selective r combination oi -control. signal 'A,'the WOB-qsignal on 260 gallons per minline 152;, and the RS signal'on line 155. Control signal I C willbe eta logic 51" level-whenever all three inputs as being controlled by thei output of the weight-bn-drill a I bit comparators specificallytheoutput of amplifier ll4-of-the weighton-drill bitcomparator 83 is applied I r from line 53 directly to' an PET switch 180. Switch 1 180 is'utilized to'set the'aniplifier 18-1 which time'in'te grates the reference voltagefvywhen the weighton bit to. the AND gate 1'70 areata logic lFleveLthercby I indicating that the mud flow rate 'has,initiallyexceeded y 300gallons per minute and has not dropped below 200 i gallons per minute that the Weighton-drillbitiisless 1,000 pnunds,-and that the rotary speed of the drill string. is greater than 50 RPM but is 'less than 100 RPM. a i r 1 A fourthcontrol signal 150', the WQBsignal on line 153, and .the-RSsignal'on line .154. The control signal D isat a logic 1. level r wheneverxeach-of. the four inputs toAND gate-1'31 is at alog'ic l""-level, thereby indicating that the mud 5* flow'rate hasinitiallycxceeded 300'gallons perminute and has then droppedbelow 300gallonsper minute but? 'stillexceedsZQQ gallons per minute, thatthe weight onw drill bit is greater than 10,000pounds, and that the ro tary speed'is less than 5 RPM. a o Finally, a fifth signal E is generated by theselective combinationof the MFR signal online filly-the WOB signal on line 1S3,andthe RS signal on line .154; Con-. dtrol signal E is-therefore a logic 'PieVelWhenever each ofthe three inputs to AN!) gate'l73 isat a logic 1" level, indicating that the mud flow rate is greater than 200 gallons per minute, that the weight on bit is greater than 10,000 pounds, and that the rotary speed is less than 5 RPM.

The foregoing control signals A-E have been illustrated as examples of selective combinations of those signals on lines 150-155 which may be utilized to control downhole operations in a borehole.

In the foregoing description, surface-to-downhole communication is initiated by changing from the surface of the earth the conditions that exist in a plurality of communication channels and by detecting, at the downhole location, the changes to the absolute value of the conditions in the communication channels. In an alternate embodiment of the present invention, any one or more of the communication channels may have its condition time integrated and the integral of the parameter utilized as the communication channel. The example of turning the downhole acoustic transmitter ON above some desired flow rate has already been discussed. Another example which would illustrate the time integral aspect is that of turning the acoustic transmitter ON when the mud flow rate exceeds a certain rate and then to change the data communication format from some initial mode to a standard transmitting mode after a given interval of time. An example of this is the situation wherein the initial transmitting mode is one in which sync words may come more often than is desirable in the standard transmitting mode.

Referring now to FIG. 7 there is illustrated an integrator which may be effectively utilized with any one of the comparators 81, 83, or 85 of FIG. 6. For purposes of illustration, the integrator of FIG. 7 is shown B is produced by the selective, combinationofcontrolsignalA, the MFR'signal on lineis greater than-10,000 pounds and which resets the amplifier 18! to. zerowhen the weighton bit-is .lessthan l0,000 pounds. (Ionsequently, theamplifier 1814s zero when the signal. on line 153 is logic :ilf :and is a smoothly increasi-ng function from the moment the sig- I nail on line 1 53 become a logic 1". The ou-tputof arriplifier lSlis. negative and fed through 'aresistor- I82 to the input of an amplifier 184: The negative input terminal'of amplifier. 184 is held=at a positive voltage by 1 resistor ISS-untllsuch timeas the eutput voltage of amlplifier 181 exceeds ina negative'direction the value of the positive-referencevoltage V Atsuch-time, the 1 --input tothe amplifier 184' becomes negative and'its loop-from theoutput o-fthe amplifier 184 to-itsnegative 1 input terminal. Theizenerdiode serves thepurposeof preventing thcoutput of the amplifier L84 fromgoing.

below. zero volts or abovea positive-'5' volts: The values oftheresistor187fand capacitor 188cm selected to providefor anRC'timeconstant of) seconds; when r r q the 'weighton bit initially exceeds 10,000 pounds, a

' logic 1" signal is appliedito theinput of switch and the l0-second time period begins to rnni At the end of'thc lD-secortdtime period,theiamplifier181 provides-a-negativeoutput whichtriggers the' amplifier 18410 a logic"-"l state lf during this'lOeecorid'time period theweight onbit'drops below 10,000 pounds,

the input to the switch 180 becomes a logic 0 signal and the switch 180 resets the amplifier 181, thereby re-' starting the lO-second time period set by the RC time constant of resistor 187 and capacitor 188. Therefore, the weight-on-bit integrator of FIG. 7 is a time integrator which is at a logic 1 state only after the weight on bit has exceeded 10,000 pounds for a continuous time period of 10 seconds or more.

Any number of communication channels may be time integrated in accordance with the foregoing example for the weight-on-drill-bit communication channel. The time integrals may be utilized either separately as control signals or in selective combinations with the output signals representing changes, with respect to a reference level, of the absolute value of the communication channel conditions. The control signals soproduced may be utilized to control a variety of downhole operations.

Control signal A has been illustrated as one example of a control signal which may be utilized to control the operation of the acoustic transmitter illustrated in H65. 2 and 3. Control signal A may be applied as illustrated in FIG. 3 to the DC/AC inverter 53 to enable the DC/AC inverter 53 to apply required power to the induction motor 66 for starting the acoustic transmitter when the mud flow rate initially exceeds 300 gallons per minute. At such time as the mud flow rate thereafter drops below 200 gallons per minute, the DC/AC inverter 53 is disabled by control signal A and the induction motor 66 of the acoustic transmitter is shut down.

the information which is to be communicated upward by the acoustic transmitter. For example, transducer 76 might provide data relating to torque, weight on bit, temperature, resistivity, hole deviation, hole direction, gamma ray, etc. This information is multiplexed by means of multiplexers 77 and transmitted uphole by means of modulation of the acoustic transmitter. It may be desirable to select only certain of these downhole measured conditions for transmission uphole or at what times and in what sequence such measured conditions are transmitted uphole. The operator may wish to telemeter only one downhole measured condition for some period of time. In such case, the operator can, from the surface of the earth, signal downhole by means of the available communication channels to change the format of the multiplexers to permit transmission of only the desired downhole measured condition. It may, for example, be desirable to transmit this information only when drilling operations are ceased. Therefore, a control signal such as control signal D may be utilized wherein at least one of the communication channel conditions required for the production of control signal D is that the rotary speed of the drill bit string be less than RPM.

In another example, it might be advantageous to initiate calibration of the downhole equipment from the surface of the earth. In this manner, the operator initiates calibration by producing, for example, the control signal C. Control signal C is applied to the multiplexer 77 to initiate transmission of calibration information under the condition wherein the mud flow rate is sufficient to permit acoustic transmitter operation, the weight on the drill bit is less than 1,000 pounds (that is, drilling operation has effectively ceased), and the rotary speed of the drill string is between 50 RPM and 100 RPM.

It may also be desirable to control the upward communication data rate. This may be carried out by changing the baud setting of the data transmission. The upward communication data rate is a function of signal strength which reduces with depth and other factors, thereby provision for changing the baud setting is advantageous so that a maximum data rate consistent with signal-to-noise ratio within the system may be maintained. An initial baud setting may be set by utilization of control signal B, for example. In this situation, the initial baud length is set when the mud flow rate exceeds 200 gallons per minute but has not yet reached 300 gallons per minute, under which circumstances the acoustic transmitter is OFF. If at any time after the acoustic transmitter is turned ON and it is desirable to change the initial baud setting, this may be accomplished by setting those drilling conditions which generate control signal E. Control signal E may be utilized, for example, to initiate a baud change when the weight on bit is greater than 10,000 pounds, the mud flow rate is greater than 300 gallons per minute, and the rotary speed of the drill string is less than 5 RPM. As the data communication rate is provided by the encoder 74 of the modulation unit, the initial baud setting and baud change controls may be initiated by applying the controls B and E, respectively, from the communication control section to the encoder 74.

Another utilization of the control signals may be that of controlling the operation of the downhole transducers from the surface of the earth. For example, some of these transducers may consume excessive power from Reference Designation the electrical system and it may be desirable to operate these transducers only at selective time intervals, thereby saving electrical power. Such a control signal may be applied to the transducers 76 to carry out this desired control.

It is to be understood that the foregoing detailed description of the generation of the power required to operate the acoustic transmitter, of the transducers, and of the generation and modulation of the acoustic waves represents the operation of one embodiment ofa borehole logging-while-drilling system suitable for control by the communication control system of the present invention. This communication control system may be utilized with various modifications to the power source, the acoustic transmitter, the transducers, and the modulation section without departing from the scope and spirit of the invention. Analog as well as digital communication may be utilized. Various modulation techniques such as, for example, amplitude modulation, frequency shift keying, or phase shift keying may be utilized.

It is to be further understood that the circuitry illustrated in detail in FIGS. 5, 6, and 7 is merely representative of one embodiment of the communication control system of the present invention. In accordance with such embodiment, the following TABLE I sets forth specific types and values of the circuit components.

TABLE I Description 2N2907 (Texas Instruments) Transistors 102 and I 3 Diode D1 620 (Texas Instruments) All inverting amplifiers MCl556G (Motorola) Flip-flop I60 SN747l (Texas Instruments) 2N3993 (Motorola) lNl (Texas Instruments) SN7400 Series (Texas Instruments) EA-OG-ZSOBB-SOO (Micro-Measurements) Switch (PET) I80 All Zener diodes All inverters Shain gua ges I and Till Voltage V +l5 volts DC V l5 volts DC V +5 volts DC What is claimed is:

1. A method of controlling downhole operations in a logging-while-drilling system including a drill bit connected to a drill string through which a drilling fluid is circulated, comprising:

a. selecting from the surface of the earth the conditions of each of a plurality of operating parameters of the system,

b. measuring the conditions of each of said plurality of operating parameters at a downhole location and producing a plurality of output signals representing the conditions of said operating parameters,

c. producing at said downhole location a plurality of reference signals, at least one reference signal being produced for each of said operating parameters,

d. comparing said output signals with their corresponding reference signals,

e. producing first comparison signals of a first state when said output signals exceed the reference signals to which they are compared in step (d) and of a second state when said output signals do not exceed the reference signals to which they are compared in step (d),

. gating selective combinations of said first comparison signals to produce a plurality of control signals when each comparison signal of a selected combination is of a required state, each said control signal being thereby produced in response to a plurality of the conditions selected in step (a) for each of said operating parameters, and

g. utilizing said control signals to control downhole operations.

2. The method of claim 1 further comprising:

.a. producing a. time integral for at least one of said output signals,

b. comparing said time integral with the reference signal corresponding to the operating parameter represented by said one of said output signals,

c. producing second comparison signals of a first state when said time integral exceeds the reference signal to which it is compared in step (b) and of a second state when the time integral does not exceed the reference signal to which it is compared in step (b), and

d. gating selective combinations of said first and second comparison signals to produce a plurality of control signals when said comparison signals of a selected combination are all of a required state, said control signals being thereby produced in response to both the conditions selected in step (a) for each of said operating parameters and the time periods during which said operating parameters remain in the selected conditions.

3. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the weight of the drill bit.

4. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the rotary speed of the drill string.

5. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the flow rate of the drilling fluid.

6. A system for controlling, from the surface of the earth, a plurality of downhole operations in a drilling system, comprising:

a. a plurality of means located on the surface of the earth for controlling each of a plurality of the operating parameters of the drilling system,

b. a plurality of subsurface means for detecting the conditions of said plurality of operating parameters, and for producing output signals representative of said conditions,

0. a plurality of subsurface means for producing a plurality of reference signals, at least one reference signal corresponding to each of said output signals,

d. a plurality of subsurface means for comparing said output signals with their corresponding reference signals and for producing comparison signals of a first state when the output signals exceed their corresponding reference signals and of a second state when the output signals do not exceed their corresponding reference signals, and

e. subsurface means for selectively gating combinations of said comparison signals to provide for a plurality of control signals to be utilized in the control of downhole operations of the drilling system, whereby any one of said control signals may be produced by selectively controlling from the surface of the earth the conditions of the operating parameters of the drilling system such that each resulting comparison signal of a selected combination of comparison signals is of the required state to produce a control signal.

7. The system of claim 6 further including at least one integrator to which at least one of said output signals and its corresponding reference signal are applied, said integrator providing a time integral signal of a first state when the integral of said one of said output signals exceeds its corresponding reference signal for a predetermined time interval and of a second state when the integral of said one of said output signals does not exceed the reference signal for a predetermined time interval, said time integral signal being selectively applied to said plurality of gates along with said comparison signals, whereby said control signals may be produced by selectively controlling from the surface of the earth both the conditions of the operating parameters of the drilling system and the time periods during which said operating parameters remain in the selected condi tions.

8. In a logging-while-drilling system employing a drill bit connected to a rotary drill string through which a drilling fluid is circulated by means of a surface pump, a plurality of downhole transducers for measuring the conditions of the operating parameters, and an acoustic transmitter for telemetering the information from the downhole location to the surface of the earth, the combination comprising:

a. means located on the earths surface for selecting the conditions of the operating parameters of the logging-while-drilling system, said plurality of transducers producing output signals indicative of the selected conditions of each of said operating parameters,

b. means located downhole for producing a plurality of reference signals, at least one reference signal being produced for each of said operating parameters,

c. a plurality of first downhole comparators which compare said output signals with the corresponding reference signals and provide a plurality of first comparison signals, said first comparison signals being of a first state when the output signals exceed the corresponding reference signal and of a second state when the output signals do not exceed the corresponding reference signals, and

d. a plurality of gates to which said first comparison signals are selectively connected, said gates providing control signals each in accordance with the states of the selected combinations of the first comparison signals to which they are connected, said control signals being thereby provided to control various downhole operations of the logging-whiledrilling system by selecting from the surface of the earth the conditions of the operating parameters.

9. The system of claim 8 further including:

a. means for producing time integrals of said output signals,

b. a plurality of second downhole comparators which compare said time integrals with the corresponding reference signals and for producing second comparison signals of a first state when said time integrals exceed said reference signals and of a second state when said time integral does not exceed said reference signals, and

c. a plurality of gates to which said second comparison signals are selectively connected for providing control signals in accordance with the states of the selected combinations of said second comparison signals, whereby said control signals are selectively produced by controlling from the surface of the earth the time periods during which said operating parameters remain in the selected conditions.

10. The system of claim 8 wherein at least one of said control signals is utilized to control operation of the downhole acoustic transmitter.

11. The system of claim 8 wherein at least one of said control signals is utilized to control the calibration of downhole equipment.

12. The system of claim 8 wherein at least one of said control signals is utilized to control the data rate of the information representing the measured downhole conditions and which is telemetered uphole by means of the acoustic transmitter.

13. The system of claim 8 wherein at least one of said control signals is utilized to control the sequence in which the measured downhole conditions are telemetered upholc by means of the acoustic transmitter.

14. The system of claim 8 wherein one of the operating parameters is the weight on the drill bit.

15. The system of claim 8 wherein one of the operating parameters is the rotary speed of the drill string.

16. The system of claim 8 wherein one of the operating parameters is the flow rate of the drilling fluid.

UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3,800,277 Dated March 26, 1974 Inventor(s) Bobbie J. Patton, James H. Sexton and John W. Harrell It is certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:

Column 5, line 37, "detector 81" should be -detector 82-. Column 8, line 16, "signsls should be --signals--;

line 32, "voltage V hd R' should be -V line 61', "amplifier 14'' should be --amplifier 114"; same line, "th logic" should be --the logic--. Column 9, line 39, "applied" should be --applies--. Column 10, line 40, "not" should be --now-. Column 11, line 36, "200" should be -300-- Signed and sealed this 6th day of August 197A.

(SEAL) Attest: v

MCCOY- M. GIBSON, JR. C. MARSHALL DANN Attesting Officer Commissioner of Patents FORM PO-IOSO (10-69) USCOMM-DC 6O376-P69 u.s. GOVERNMENT PRINTING OFFICE: I969 0-366-334 UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTION Patent No. 3,800,277 Dated March 26, 1974 Inventor(s) Bobbie J. Patton, James H. Sexton and John W. Harrell I It is certified that error appears in the above-identified patent and that said Letters Patent are hereby corrected as shown below:

Column 5, line 37, "detector 81" should be ---detector 82--. Column 8, line 16, "signsls'" should be "signals";

line 32, "voltage V hd R" should be --V line 61, "amplifier 14" should be --amplifier ll4--; same line, "th logic" should be 'the logic--. Column 9, line 39, "applied' should be --applies--. Column 10, line 40, "not" should be --now--. Column 11, line 36, "200" should be --300-.

Signed and sealed this 6th day of August 197A.

(SEAL) Attest:

MCCOY M. GIBSON, JR. (3. MARSHALL DANN Attesting Officer Commissioner of Patents FORM po'wso I v uscoMM-oc 60376-P69 I 9 U.S. GOVERNMENT PR'NYING OFFICE I 969 0-366-334 

1. A method of controlling downhole operations in a loggingwhile-drilling system including a drill bit connected to a drill string through which a drilling fluid is circulated, comprising: a. selecting from the surface of the earth the conditions of each of a plurality of operating parameters of the system, b. measuring the conditions of each of said plurality of operating parameters at a downhole location and producing a plurality of output signals representing the conditions of said operating parameters, c. producing at said downhole location a plurality of reference signals, at least one reference signal being produced for each of said operating parameters, d. comparing said output signals with their corresponding reference signals, e. producing first comparison signals of a first state when said output signals exceed the reference signals to which they are compared in step (d) and of a second state when said output signals do not exceed the reference signals to which they are compared in step (d), f. gating selective combinations of said first comparison signals to produce a plurality of control signals when each comparison signal of a selected combination is of a required state, each said control signal being thereby produced in response to a plurality of the conditions selected in step (a) for each of said operating parameters, and g. utilizing said control signals to control downhole operations.
 2. The method of claim 1 further comprising: a. producing a time integral for at least one of said output signals, b. comparing said time integral with the reference signal corresponding to the operatIng parameter represented by said one of said output signals, c. producing second comparison signals of a first state when said time integral exceeds the reference signal to which it is compared in step (b) and of a second state when the time integral does not exceed the reference signal to which it is compared in step (b), and d. gating selective combinations of said first and second comparison signals to produce a plurality of control signals when said comparison signals of a selected combination are all of a required state, said control signals being thereby produced in response to both the conditions selected in step (a) for each of said operating parameters and the time periods during which said operating parameters remain in the selected conditions.
 3. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the weight of the drill bit.
 4. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the rotary speed of the drill string.
 5. The method of claim 1 wherein one of the operating parameters, the condition of which is selectively controlled in step (a), is the flow rate of the drilling fluid.
 6. A system for controlling, from the surface of the earth, a plurality of downhole operations in a drilling system, comprising: a. a plurality of means located on the surface of the earth for controlling each of a plurality of the operating parameters of the drilling system, b. a plurality of subsurface means for detecting the conditions of said plurality of operating parameters, and for producing output signals representative of said conditions, c. a plurality of subsurface means for producing a plurality of reference signals, at least one reference signal corresponding to each of said output signals, d. a plurality of subsurface means for comparing said output signals with their corresponding reference signals and for producing comparison signals of a first state when the output signals exceed their corresponding reference signals and of a second state when the output signals do not exceed their corresponding reference signals, and e. subsurface means for selectively gating combinations of said comparison signals to provide for a plurality of control signals to be utilized in the control of downhole operations of the drilling system, whereby any one of said control signals may be produced by selectively controlling from the surface of the earth the conditions of the operating parameters of the drilling system such that each resulting comparison signal of a selected combination of comparison signals is of the required state to produce a control signal.
 7. The system of claim 6 further including at least one integrator to which at least one of said output signals and its corresponding reference signal are applied, said integrator providing a time integral signal of a first state when the integral of said one of said output signals exceeds its corresponding reference signal for a predetermined time interval and of a second state when the integral of said one of said output signals does not exceed the reference signal for a predetermined time interval, said time integral signal being selectively applied to said plurality of gates along with said comparison signals, whereby said control signals may be produced by selectively controlling from the surface of the earth both the conditions of the operating parameters of the drilling system and the time periods during which said operating parameters remain in the selected conditions.
 8. In a logging-while-drilling system employing a drill bit connected to a rotary drill string through which a drilling fluid is circulated by means of a surface pump, a plurality of downhole transducers for measuring the conditions of the operating parameters, and an acoustic transmitter for telemetering the information from the downhole location to the Surface of the earth, the combination comprising: a. means located on the earth''s surface for selecting the conditions of the operating parameters of the logging-while-drilling system, said plurality of transducers producing output signals indicative of the selected conditions of each of said operating parameters, b. means located downhole for producing a plurality of reference signals, at least one reference signal being produced for each of said operating parameters, c. a plurality of first downhole comparators which compare said output signals with the corresponding reference signals and provide a plurality of first comparison signals, said first comparison signals being of a first state when the output signals exceed the corresponding reference signal and of a second state when the output signals do not exceed the corresponding reference signals, and d. a plurality of gates to which said first comparison signals are selectively connected, said gates providing control signals each in accordance with the states of the selected combinations of the first comparison signals to which they are connected, said control signals being thereby provided to control various downhole operations of the logging-while-drilling system by selecting from the surface of the earth the conditions of the operating parameters.
 9. The system of claim 8 further including: a. means for producing time integrals of said output signals, b. a plurality of second downhole comparators which compare said time integrals with the corresponding reference signals and for producing second comparison signals of a first state when said time integrals exceed said reference signals and of a second state when said time integral does not exceed said reference signals, and c. a plurality of gates to which said second comparison signals are selectively connected for providing control signals in accordance with the states of the selected combinations of said second comparison signals, whereby said control signals are selectively produced by controlling from the surface of the earth the time periods during which said operating parameters remain in the selected conditions.
 10. The system of claim 8 wherein at least one of said control signals is utilized to control operation of the downhole acoustic transmitter.
 11. The system of claim 8 wherein at least one of said control signals is utilized to control the calibration of downhole equipment.
 12. The system of claim 8 wherein at least one of said control signals is utilized to control the data rate of the information representing the measured downhole conditions and which is telemetered uphole by means of the acoustic transmitter.
 13. The system of claim 8 wherein at least one of said control signals is utilized to control the sequence in which the measured downhole conditions are telemetered uphole by means of the acoustic transmitter.
 14. The system of claim 8 wherein one of the operating parameters is the weight on the drill bit.
 15. The system of claim 8 wherein one of the operating parameters is the rotary speed of the drill string.
 16. The system of claim 8 wherein one of the operating parameters is the flow rate of the drilling fluid. 